Method of CO2 removal from a gasesous stream at reduced temperature

ABSTRACT

A method for the removal of H 2 O and CO 2  from a gaseous stream comprising H 2 O and CO 2 , such as a flue gas. The method initially utilizes an H 2 O removal sorbent to remove some portion of the H 2 O, producing a dry gaseous stream and a wet H 2 O removal sorbent. The dry gaseous stream is subsequently contacted with a CO 2  removal sorbent to remove some portion of the CO 2 , generating a dry CO 2  reduced stream and a loaded CO 2  removal sorbent. The loaded CO 2  removal sorbent is subsequently heated to produce a heated CO 2  stream. The wet H 2 O removal sorbent and the dry CO 2  reduced stream are contacted in a first regeneration stage, generating a partially regenerated H 2 O removal sorbent, and the partially regenerated H 2 O removal sorbent and the heated CO 2  stream are subsequently contacted in a second regeneration stage. The first and second stage regeneration typically act to retain an initial monolayer of moisture on the various removal sorbents and only remove moisture layers bound to the initial monolayer, allowing for relatively low temperature and pressure operation. 
     Generally the applicable H 2 O sorption/desorption processes may be conducted at temperatures less than about 70° C. and pressures less than 1.5 atmospheres, with certain operations conducted at temperatures less than about 50° C.

GOVERNMENT INTERESTS

The United States Government has rights in this invention pursuant to the employer-employee relationship of the Government to the inventors as U.S. Department of Energy employees and site-support contractors at the National Energy Technology Laboratory.

FIELD OF THE INVENTION

One or more embodiments of the present invention relate to the removal of H₂O and CO₂ from a gaseous stream by contacting the gaseous stream with H₂O and CO₂ removal sorbents, followed by regeneration of the H₂O and CO₂ removal sorbents under specific conditions.

BACKGROUND

Carbon dioxide from fossil fuel combustion and industrial processes is a major target in current emission reduction strategies. In particular, post-combustion CO₂ capture from the flue gas is a key technology option for retrofitting the existing fleet of power stations. Capture of CO₂ from large point sources such as fossil fueled power plants is a major concern in any strategy intended to reduce anthropogenic CO₂ emissions.

Generally, approaches for the selective removal of acid gases such as carbon dioxide from these large point sources have utilized aqueous amines, such as monoethanolamine (MEA), diethanolamine (DEA), diglycol-amine (DGA), N-methyldiethanolamine (MDEA), and 2-amino-2-methyl-1-propanol (AMP). This effort has largely extended from successful uses in applications such as gas streams in natural gas, refinery off-gases and synthesis gas processing, however those particular gas streams are generally at high pressures. These approaches suffer when applied to CO₂ capture from fossil-fueled based flue gases, which present large volumetric flow rates at low total pressure, temperature generally around 100-150° C., large amounts of CO₂ at low partial pressure, and significant H₂O content. As a result, large scale applications are hindered by a variety of challenges, such as cost of scale up, energy cost of regeneration, solvent degradation, the potential environment impacts of the solvents, and others.

Another approach to post-combustion CO₂ capture from large point sources has utilized reversible CO₂ capture by solid removal sorbents. These solid removal sorbents can provide advantages compared to other techniques, such as reduced energy for regeneration, greater capacity, selectivity, ease of handling, and others. In particular, the regeneration energy requirement for CO₂ capture using solid removal sorbents is significantly less than the aqueos amine-based process, because of the absence of large amounts of water and comparatively lower heat capacities. A variety of solid materials have been utilized, including porous carbonaceous materials, zeolites, alumina, silica gels, and metal-organic frameworks. However, the presence of water vapor, which is an inevitable component in flue gas, may negatively affect the capacity of these removal sorbents and reduces the availability of the active surface area.

Solid removal sorbents such as zeolites and others can become easily deactivated by moisture in the gas process stream. Current state of the art CO₂ removal techniques generally involve either capturing moisture with the CO₂ or removing the moisture prior to capturing the CO₂. Removing the moisture prior to capture can be costly in both capital and energy, since typically the moisture removal sorbent must be heated for sorbent regeneration. See e.g., U.S. patent application Ser. No. 12/419,513 by Jain, published as U.S. Pub. No. 2010/0251887, published Oct. 7, 2010; see also Ishibashi et al., “Technology for Removing Carbon Dioxide from Power Plant Flue Gas by the Physical Adsorption Method,” Energy Convers. Mgmt 37 (1996). These processes typically detail moisture removal sorbent regenerations at temperatures of at least 80° C. and in some situations up to 300° C., in order to fully regenerate the H₂O removal sorbent and remove substantially all adsorbed moisture before re-use in a cycle. The additional heat required for these temperatures is supplied through some means such as power plant steam or electrical heating, and dramatically increase plant efficiencies associated with capture. In some cases, moisture removal requires more than 30% of the total energy of the CO₂ removal process.

It would be advantageous if a post-combustion CO₂ removal process utilizing a solid removal sorbent were available where H₂O could be reduced prior to CO₂ capture in a more economical manner. It would particularly advantageous if the process could utilize relatively low temperature and pressures for the H₂O and CO₂ sorption, mitigating the impact on overall efficiency. It would be additionally advantageous if the process could effectively utilize the low partial pressures of various gases in existing process streams and operate the cycle with an H₂O removal sorbent which is only partial regenerated, in order to avoid the relatively high penalties associated the full regeneration processes typically employed.

Disclosed here is a method for the removal of H₂O and CO₂ from a gaseous stream such as a flue gas, where the method utilizes first and second stage regenerations to affect an overall regeneration sufficient for a cyclic operation. The first and second regenerations utilize the low partial pressures of CO₂ and H₂O within the process streams of the method, and are effective at relatively low temperatures and pressures. The regenerations generally act only to remove moisture layers contained in the multi layers bound to an initial monolayer on the various described H₂O removal sorbents, allowing the Gibbs free energy of mixing to largely compensate for the heats of reaction, and largely avoiding the additional heats required for removal of the initial monolayer. Generally the applicable H₂O sorption/desorption processes may be conducted at temperatures less than about 70° C. and pressures less than 1.5 atmospheres, with certain operations conducted at temperatures less than about 50° C.

These and other objects, aspects, and advantages of the present disclosure will become better understood with reference to the accompanying description and claims.

SUMMARY

The present disclosure is directed to a method for the removal of H₂O and CO₂ from a gaseous stream comprising H₂O and CO₂, such as a flue gas. The method generally comprises (i) contacting the gaseous stream and an H₂O removal sorbent at a first temperature and transferring a portion of the H₂O to the H₂O removal sorbent, and generating a wet H₂O sorbent and a dry gaseous stream; (ii) contacting the dry gaseous stream and a CO₂ removal sorbent at a second temperature and generating a loaded CO₂ sorbent and a dry CO₂ reduced stream; (iii) conducting a first stage regeneration by contacting the dry CO₂ reduced stream and the wet H₂O sorbent at a third temperature and transferring a first quantity of H₂O from the wet H₂O sorbent, and generating a partially regenerated H₂O removal sorbent and an H₂O exhaust stream; (iv) heating the loaded CO₂ removal sorbent to a fourth temperature and desorbing a gaseous CO₂, generating a regenerated CO₂ removal sorbent and a heated CO₂ stream; (v) conducting a second stage regeneration by contacting the heated CO₂ stream and the partially regenerated H₂O sorbent at a fifth temperature and transferring a second quantity of H₂O from the partially regenerated H₂O sorbent, and generating a regenerated H₂O removal sorbent and a CO₂ exhaust stream; and (vi) using the regenerated H₂O sorbent as the H₂O sorbent and using the regenerated CO₂ removal sorbent as the CO₂ sorbent, and repeating the preceding steps in a cyclic process.

The use of the various process streams to affect a first and second stage regeneration in this manner allows relatively low temperature partial pressure changes to affect an overall regeneration sufficient for a cyclic operation that incorporates some degree of H₂O removal prior to contact with a CO₂ sorbent. The method is particularly advantageous for CO₂ removal operations where the presence of H₂O above certain levels may be detrimental to the CO₂ sorbent. The first and second regenerations typically provide only a partial regeneration of the H₂O sorbent, such that the various H₂O sorbents retain an initial monolayer of moisture throughout the cycle while moisture layers bound to the initial monolayer are removed. This approach enables relatively low temperature and pressure operation by allowing the Gibbs free energy of mixing to compensate for the heat of reaction required to remove the additional moisture layers, while avoiding the necessity to provide additional heat of reaction for removal of the initial monolayer. The method thus largely utilizes the Gibbs free energy of mixing enabled through the partial pressure swings generated by both the dry CO₂ reduced stream and the heated CO₂ stream for effective moisture removal, allowing the relatively low temperature and pressure operation.

In an embodiment, the first temperature, the second temperature, the third temperature, and the fifth temperature are less than 70° C. In a further embodiment, the first temperature, the second temperature, and the third temperature are less than 50° C. and the fifth temperature is greater than 50° C. In another embodiment, the various operations described by the cycle are conducted at a pressure less than 1.5 atmospheres. The method is particularly advantageous for CO₂ removal operations where the presence of H₂O above certain levels may be detrimental to the CO₂ sorbent.

The novel process and principles of operation are further discussed in the following description.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 illustrates the various processes within the disclosed cycle.

FIG. 2 illustrates a specific embodiment of the disclosed cycle.

DETAILED DESCRIPTION

The following description is provided to enable any person skilled in the art to use the invention and sets forth the best mode contemplated by the inventor for carrying out the invention. Various modifications, however, will remain readily apparent to those skilled in the art, since the principles of the present invention are defined herein specifically to provide a method for the removal of H₂O and CO₂ from a gaseous stream comprising H₂O and CO₂.

Generally, the present disclosure is directed to a method for the removal of H₂O and CO₂ from a gaseous stream comprising H₂O and CO₂, such as a flue gas. Generally the method initially utilizes and H₂O sorbent to remove some portion of the H₂O, producing a dry gaseous stream and a wet H₂O sorbent. The dry gaseous stream is subsequently contacted with a CO₂ sorbent to remove some portion of the CO₂, generating a dry CO₂ reduced stream and a loaded CO₂ sorbent. The loaded CO₂ sorbent is subsequently heated to produce a heated CO₂ stream.

The wet H₂O sorbent and the dry CO₂ reduced stream are subsequently contacted and a first quantity of the H₂O transferred from the gaseous stream is removed from the wet H₂O sorbent, generating a partially regenerated H₂O sorbent. Following this, the partially regenerated H₂O sorbent and the heated CO₂ stream are contacted and a second quantity of the H₂O transferred from the gaseous stream is removed from the partially regenerated H₂O sorbent, producing a regenerated H₂O sorbent. The use of a first and second stage regeneration in this manner allows relatively low temperature partial pressure changes to affect an overall regeneration sufficient for a cyclic operation which incorporates some degree of H₂O removal prior to contact with a CO₂ removal sorbent. The method is particularly advantageous for CO₂ removal operations where the presence of H₂O above certain levels may be detrimental to the CO₂ removal sorbent.

Generally, the first and second regenerations are expected to only provide a partial regeneration of the H₂O removal sorbent, such that the various H₂O removal sorbents retain an initial monolayer of moisture and typically the dry CO₂ reduced stream and the heated CO₂ stream only act to remove moisture layers bound to the initial monolayer. This approach enables relatively low temperature and pressure operation by allowing the Gibbs free energy of mixing to compensate for the heat of reaction required to remove the additional moisture layers, while avoiding the necessity to provide additional heat of reaction for removal of the initial monolayer. The method thus largely utilizes the Gibbs free energy of mixing enabled through the partial pressure swings generated by both the dry CO₂ reduced stream and the heated CO₂ stream for effective moisture removal, allowing the relatively low temperature and pressure operation. Generally the applicable H₂O sorption/desorption processes may be conducted at temperatures less than about 70° C. and pressures less than 1.5 atmospheres, with certain operations conducted at temperatures less than about 50° C.

A general description of the embodiment of the low temperature CO₂ removal process is illustrated at FIG. 1. At FIG. 1, a gaseous stream G₁ comprised of CO₂ and H₂O contacts an H₂O removal sorbent 101 at a first temperature. H₂O removal sorbent 101 sorbs some portion of the H₂O in gaseous stream G₁, transferring H₂O from gaseous stream G₁ to H₂O removal sorbent 101. The transfer of H₂O from gaseous stream G₁ generates wet H₂O removal sorbent 102 and dry gaseous stream G₂. Dry gaseous stream G₂ is generally gaseous stream G₁ less the H₂O transferred from gaseous stream G₁ to H₂O sorbent 101, while wet H₂O sorbent 102 generally comprises H₂O removal sorbent 101 and the H₂O transferred from gaseous stream G₁ and sorbed on H₂O removal sorbent 101. Correspondingly, dry gaseous stream G₂ generally comprises the CO₂ from gaseous stream G₁ with a reduced amount of H₂O.

In an embodiment, the first temperature is less than 70° C. In another embodiment, the first temperature is less than 50° C. and the moisture content of gaseous stream G₁ is less than 10 volume percent (vol. %). In a further embodiment, gaseous stream G₁ and dry H₂O removal sorbent 102 are contacted at a Gas Hourly Space Velocity (GHSV) of less than about 1500 h⁻¹. In an additional embodiment, dry gaseous stream G₂ has a moisture content of less than 0.1 volume percent (vol. %) H₂O, and in still another embodiment, dry gaseous stream G₂ has a moisture content between 0.1 vol. % and 0.02 vol. %. In still another embodiment, contact between gaseous stream G₁ and a dry H₂O removal sorbent 101 occurs at a pressure less than 1.5 atmospheres.

Following production of dry gaseous stream G₂, dry gaseous stream G₂ is contracted with CO₂ removal sorbent 105 at a second temperature. CO₂ removal sorbent 105 sorbs some portion of the CO₂ remaining in gaseous stream G₂, transferring CO₂ from dry gaseous stream G₂ to CO₂ removal sorbent 105. The transfer of CO₂ from dry gaseous stream G₂ to CO₂ removal sorbent 105 generates loaded CO₂ removal sorbent 106 and dry CO₂ reduced stream G₃. Dry CO₂ reduced stream G₃ is generally dry gaseous stream G₂ less the CO₂ transferred from dry gaseous stream G₂ to CO₂ removal sorbent 105, while loaded CO₂ removal sorbent 106 generally comprises CO₂ removal sorbent 105 and the CO₂ transferred from dry gaseous stream G₂ and sorbed on CO₂ removal sorbent 105. In an embodiment, the second temperature is less than 70° C. In a further embodiment, the second temperature is less than 50° C. In still another embodiment, contact between dry gaseous stream G₂ and a CO₂ removal sorbent 105 occurs at a pressure less than 1.5 atmospheres.

Having now generated dry CO₂ reduced stream G₃ and H₂O removal sorbent 102, wet H₂O removal sorbent 102 is partially regenerated through contact with dry CO₂ reduced stream G₃ at a third temperature. The contact transfers a first quantity of H₂O from wet H₂O removal sorbent 102 to dry CO₂ reduced stream G₃, where the first quantity of H₂O is an amount of the H₂O transferred from gaseous stream G₁ to H₂O removal sorbent 101. The contact additionally generates partially regenerated H₂O removal sorbent 103 and H₂O exhaust stream G₄. Partially regenerated H₂O removal sorbent 103 generally comprises wet H₂O removal sorbent less the amount of H₂O transferred to dry CO₂ reduced stream G₃ from wet H₂O removal sorbent 102, while H₂O exhaust stream G₄ generally comprises dry CO₂ reduced stream G₃ and the amount of H₂O transferred to dry CO₂ reduced stream G₃ from wet H₂O removal sorbent 102.

As indicated, contact between dry CO₂ reduced stream G₃ and wet H₂O removal sorbent 102 generally provides only a partial regeneration of wet H₂O removal sorbent 102, so that following this contact, partially regenerated H₂O removal sorbent 103 typically retains a significant fraction of the H₂O sorbed onto wet H₂O removal sorbent 102. In an embodiment, wet H₂O removal sorbent 102 has a first moisture content and partially regenerated H₂O removal sorbent 103 has a second moisture content, where the second moisture content is equal to at least 50% of the first moisture content. Here, “first moisture content” means the mass of H₂O sorbed on wet H₂O removal sorbent 102 following the contact between H₂O removal sorbent 101 and gaseous stream G₁, and “second moisture content” means the mass of H₂O sorbed on partially regenerated H₂O removal sorbent 103 following the contact between wet H₂O removal sorbent 102 and dry CO₂ reduced stream G₃. Here and elsewhere within this disclosure, “H₂O sorbed” when used in reference to an H₂O removal sorbent means H₂O adsorbed or absorbed on a non-H₂O material comprising the H₂O removal sorbent, and H₂O hydrogen bonded to one or more H₂O molecules, were the one or more H₂O molecules are adsorbed or absorbed on the non-H₂O material. Further, within this disclosure, the “mass of H₂O sorbed” on a particular removal sorbent means the total mass of H₂O sorbed by the comprehensive mass of the particular removal sorbent designated either following or preceding a described gaseous contact. For example, if wet H₂O removal sorbent 102 comprises a plurality of individual removal sorbent pellets where the plurality has been contacted with dry CO₂ reduced stream G₃, the mass of H₂O sorbed on wet H₂O removal sorbent 102 refers to the total mass of H₂O sorbed by the plurality of individual removal sorbent pellets comprehensively following contact with dry CO₂ reduced stream G₃.

Moisture contents as described here may be determined using various means known in the art. For example, the moisture contents for a specific H₂O removal sorbent under a given set of expected or experienced conditions such as temperature, total pressure, partial pressure of surrounding gases, and other physical parameters may be determined using moisture sorption isotherms for the specific H₂O removal sorbent. Alternatively, moisture contents may be determined experimentally for a given H₂O removal sorbent based on reproduction of the expected or experienced conditions. See e.g., Bell, L. N., and Labuza, T. P, Practical Aspects of Moisture Sorption Isotherm Measurement and Use, (2nd Ed., 2000).

In another embodiment, the partial regeneration is reflected by a first mass flow rate of H₂O in gaseous stream G₁ compared to a second mass flow of H₂O in H₂O exhaust stream G₄, where the second mass flow rate of H₂O is less than 70% of the first mass flow rate of H₂O. For example, gaseous stream G₁ may have a first mass flow rate of H₂O of about 4.5 kg/h prior to contact with dry H₂O removal sorbent 101, while H₂O exhaust stream G₄ has a second mass flow rate of H₂O of about 2.5 kg/h following contact with wet H₂O removal sorbent 102, such that the second mass flow rate is about 56% of the first mass flow rate. In another embodiment, the second mass flow rate is greater than about 40% and less than about 70% of the first mass flow rate.

This particular approach of partial regeneration allows for utilization of relatively reduced temperatures during the contact. Correspondingly, the integrated nature by which the preceding processes combine to generate dry CO₂ reduced stream G₃ may similarly be conducted at relatively reduced temperatures, avoiding the necessity of additional heat inputs. For example, contact between gaseous stream G₁ and H₂O removal sorbent 101, contact between dry gaseous stream G₂ and CO₂ removal sorbent 105, and contact between dry CO₂ reduced stream G₃ and wet H₂O removal sorbent 102 may be conducted at temperatures less than about 50° C. and pressures less than about 1.5 atmospheres.

Further regeneration of partially regenerated H₂O removal sorbent 103 occurs through regeneration of loaded CO₂ removal sorbent 106 and generation of heated CO₂ stream G₅. Loaded CO₂ removal sorbent 106 is heated to a fourth temperature through the heat input Q, and the loaded CO₂ removal sorbent desorbs the CO₂ gained during the contact between dry gaseous stream G₂ and CO₂ removal sorbent 105 at the second temperature. The fourth temperature is greater than the second temperature. The increased temperature causes loaded CO₂ removal sorbent 106 to desorb gaseous CO₂ and regenerated CO₂ removal sorbent 107, where regenerated CO₂ removal sorbent 107 generally comprises loaded CO₂ removal sorbent 106 less the gaseous CO₂ desorbed. Additionally, at least some portion of the gaseous CO₂ desorbed comprises heated CO₂ stream G₅. In a particular embodiment, the fourth temperature is greater than 160° C.

Having now generated heated CO₂ stream G₅ and partially regenerated H₂O removal sorbent 103, partially regenerated H₂O removal sorbent 103 is further regenerated through contact with heated CO₂ stream G₅ at a fifth temperature. The contact transfers a second quantity of H₂O to heated CO₂ stream G₅ from partially regenerated H₂O removal sorbent 103, where the second quantity of H₂O is another amount of the H₂O transferred from gaseous stream G₁ to H₂O removal sorbent 101. The contact further generates regenerated H₂O removal sorbent 104 and CO₂ exhaust stream G₆. Regenerated removal sorbent 104 generally comprises partially regenerated H₂O removal sorbent less the second quantity of H₂O transferred to heated CO₂ stream G₅ from partially regenerated H₂O removal sorbent 103, while CO₂ exhaust stream G₆ generally comprises heated CO₂ stream G₅ and the second quantity of H₂O transferred to heated CO₂ stream G₅ from partially regenerated H₂O removal sorbent 103.

Due to the partial regeneration of wet H₂O removal sorbent 102 conducted earlier in the process, CO₂ exhaust stream G₆ and H₂O exhaust stream G₄ will have a combined mass flow rate of H₂O generally equal to the first mass flow rate of H₂O in gaseous stream G₁. In an embodiment, CO₂ exhaust stream G₆ exhibits a third mass flow rate of H₂O, where the third mass flow rate is less than about 60% of the first mass flow rate. In another embodiment, the third mass flow rate is greater than about 30% and less than about 60% of the first mass flow rate. In a further embodiment, the third mass flow rate of H₂O in CO₂ exhaust stream G₆ is less than the second mass flow rate of H₂O in H₂O exhaust stream G₄, so that a majority of the first mass flow rate of H₂O entering the process via gaseous stream G₁ exits via H₂O exhaust stream G₄.

Having produced both regenerated H₂O removal sorbent 104 and generated CO₂ removal sorbent 107, the steps of the process are repeated using regenerated H₂O removal sorbent 104 as H₂O removal sorbent 101 and using regenerated CO₂ removal sorbent 107 as CO₂ removal sorbent 105, as represented by process paths P₁ and P₂ respectively.

The first and second regenerations within the process disclosed are generally intended to remove some portion of the sorbed H₂O while leaving an initial monolayer of H₂O intact. Generally, moisture loadings on H₂O removal sorbents comprise an initial monolayer sorbed on non-H₂O removal sorbent materials, accompanied by additional upper layers of H₂O, where the additional upper layers are retained through isosteric sorption with the initial monolayer. The heat of reaction necessary to remove the initial monolayer greatly exceeds that required to remove an additional upper layer. For example, in an H₂O removal sorbent of activated alumina, about 40 kJ/mol might be required to remove the initial monolayer, while only about 3-10 kJ/mol may be required to remove an additional upper layer. However, the Gibbs free energy of mixing when moisture is introduced into a sweeping gas is estimated at around 8 kJ/mol. Thus, by providing an H₂O removal sorbent regeneration whereby typically only the additional upper layers of moisture are removed while the initial monolayer is largely retained, the Gibbs free energy of mixing largely compensates for the 3-10 kJ/mol required without an attendant heat of reaction penalty.

Within the particular cycle disclosed here, the generally low temperatures employed leave the initial monolayer of H₂O sorbed onto H₂O removal sorbent 101 intact, in order to avoid the high heats of reaction required to remove that monolayer. Generally within this disclosure, the contact between dry CO₂ reduced stream G₃ and wet H₂O removal sorbent 102 as well as the contact between heated CO₂ stream G₅ and partially regenerated H₂O removal sorbent 103 is only intended to remove moisture layers bonded to the initial monolayer of H₂O sorbed on H₂O removal sorbent 101, rather than the initial monolayer itself. Such an approach avoids the high energy penalties associated with desorption of the initial monolayer of H₂O while retaining sufficient H₂O removal capabilities in the H₂O removal sorbent. The relatively low temperatures allows the two-stage regeneration to provide sufficiently viable moisture removal capability over the cycle while greatly mitigating energetic losses from an associated power cycle responsible for providing the heating requirements. As a result, in an embodiment, the first temperature, the second temperature, the third temperature, and the fifth temperature are less than 70° C. In a further embodiment, the first temperature, the second temperature, and the third temperature are less than 50° C. In another embodiment, the first temperature, the second temperature, and the third temperature are greater than 25° C. and less than 50° C.

Additionally, allowing retention of the initial monolayer of moisture on the H₂O removal sorbent throughout the cycle enables effective swing processes based largely on changes in partial pressure, providing for effective sequential use of the various streams generated over the process. By typically removing only the additional upper layers of moisture while the initial monolayer is largely retained, the greatly reduced H₂O partial pressures of dry CO₂ reduced stream G₃ and heated CO₂ stream G₅ are effective for sufficient moisture removal based on the shifts in partial pressures alone, and in a manner that allows the Gibbs free energy of mixing to compensate in a manner that avoids the otherwise necessary heat penalties. Correspondingly, the absorption process producing wet H₂O removal sorbent 102 and the sequential regeneration processes producing partially regenerated H₂O removal sorbent 103 and regenerated H₂O removal sorbent 104 may all be conducted under substantially equivalent total pressure conditions. This provides clear advantage in terms of necessary energy input into the process. Correspondingly, in an embodiment, contact between gaseous stream G₁ and H₂O removal sorbent 101, contact between dry gaseous stream G₂ and CO₂ removal sorbent 105, contact between dry CO₂ reduced stream G₃ and wet H₂O removal sorbent 102, and contact between heated CO₂ stream G₃ occurs at a total pressure of less than 1.5 atmospheres. In another embodiment, contact between gaseous stream G₁ and H₂O removal sorbent 101, contact between dry gaseous stream G₂ and CO₂ removal sorbent 105, contact between dry CO₂ reduced stream G₃ and wet H₂O removal sorbent 102, and contact between heated CO₂ stream G₅ and partially regenerated H₂O removal sorbent 103 occurs at a total pressure between 0.8 and 1.2 atmospheres.

Reflecting the intended retention of retaining at least some portion of the initial monolayer of H₂O on the H₂O removal sorbent throughout the process, in an embodiment, regenerated H₂O removal sorbent 104 has a third moisture content, where “third moisture content” means the mass of H₂O sorbed on regenerated H₂O removal sorbent 104 following the contact between partially regenerated H₂O removal sorbent 103 and heated CO₂ stream G₅. In this embodiment, the third moisture content is at least 30% of the first moisture content of wet H₂O removal sorbent 102, and at least 50% of the second moisture content of partially regenerated H₂O removal sorbent 103. Similarly, and reflecting the use of regenerated H₂O removal sorbent 104 as H₂O removal sorbent 101 in the cyclic process, in an embodiment, H₂O removal sorbent 101 has an initial moisture content, where “initial moisture content” means the mass of H₂O sorbed on H₂O removal sorbent 101 prior to the contact between H₂O removal sorbent 101 and gaseous stream G₁, and the initial moisture content is at least 30% of the first moisture content of wet H₂O removal sorbent 102. In another embodiment, the initial moisture content is at least 50% of the second moisture content of partially regenerated H₂O removal sorbent 103.

The H₂O removal sorbent may be any material which acts to sorb H₂O when placed in contact with a first gaseous stream having a first partial pressure of H₂O and acts to desorb H₂O when placed in contact with a second gaseous stream having a second partial pressure of H₂O, where the first partial pressure is greater than the second partial pressure. In an embodiment, the H₂O removal sorbent has a greater chemical affinity for H₂O than CO₂, where chemical affinity refers to the tendency of H₂O or CO₂ to aggregate on or bond with the H₂O removal sorbent. See e.g. IUPAC, Compendium of Chemical Terminology (2nd ed. 1997), among others. In an embodiment, the H₂O removal sorbent is a material having a specific surface area greater than 300 m² per gram of the material and a pore volume greater than 0.40 ml per grain of the material. In a further embodiment, the H₂O removal sorbent is an activated alumina comprising Al₂O₃, a 3A or 4A zeolite comprising aluminum, silicon, and oxygen, a silica gel comprising Na₂SiO₃, or mixtures thereof. In another embodiment the H₂O removal sorbent is an absorbent clay comprising an aluminum phyllosilicate, such as but not limited to bentonite, ball clay, fuller's earth, kaolin, attapulgite, hectorite, meerschaum, palygorskite, saponite, sepiaolite, common clay, and fire clay.

The CO₂ removal sorbent may be any material which acts to sorb CO₂ when placed in contact with a gas stream comprising CO₂ at the second temperature and acts to desorb CO₂ when heated to the fourth temperature. In an embodiment, the CO₂ removal sorbent is a solid sorbent. See e.g., Samanta et al., “Post-Combustion CO₂ Capture Using Solid Sorbents: A Review,” Ind. Eng. Chem. Res. 51 (2012), among others. In a further embodiment, the CO₂ removal sorbent comprises a 13X zeolite.

A particular embodiment of the process disclosed is illustrated at FIG. 2. At FIG. 2. A gaseous stream comprising CO₂ and H₂O enters H₂O capture reactor 211 at inlet 216. The gaseous stream entering at inlet 216 has a temperature of about 40° C. The gaseous stream may be, for example, a flue gas stream cooled to about 40° C. and comprising about 20 wt. % CO₂, about 5 wt. % H₂O, balance largely N₂. H₂O capture reactor 211 establishes the gaseous stream and an H₂O removal sorbent at a first temperature of about 40° C. and a pressure less than about 1.5 atmospheres, and the gaseous stream contacts the H₂O removal sorbent, removing some portion of the H₂O from the gaseous stream, generating a wet H₂O removal sorbent, and producing a dry gaseous stream at a temperature of about 40° C. In a particular embodiment, the dry gaseous stream has a moisture content between 0.1 vol. % and 0.02 vol. %. The dry gaseous stream is discharged from H₂O capture reactor 211 and enters CO₂ capture reactor 212 via conduit 217. The wet H₂O removal sorbent exits H₂O capture reactor 211 and enters first H₂O regeneration reactor 213 via conduit 218.

In an embodiment, the gaseous stream entering at inlet 216 derives from a flue gas stream. The flue gas stream has a temperature greater than 40° C. and typically 55-60° C., and is composed of about 20 wt. % CO₂ and about 10 wt. % H₂O. The flue gas stream is cooled by heat transfer to a cooling medium in cooler 231 to the temperature of about 40° C., and the H₂O content is reduced by about 50% to around 5 wt. %, with the removed water issuing through exit 232.

CO₂ capture reactor 212 establishes the dry gaseous stream and a CO₂ removal sorbent at a second temperature of about 40° C. and a pressure less than about 1.5 atmospheres, and the dry gaseous stream contacts the CO₂ removal sorbent, removing some portion of the CO₂ from the dry gaseous stream, generating a loaded CO₂ removal sorbent, and producing a dry CO₂ reduced stream at a temperature of about 40° C. The dry CO₂ reduced stream is discharged from CO₂ capture reactor 212 and enters first H₂O regeneration reactor 213 via conduit 219. The loaded CO₂ removal sorbent exits CO₂ capture reactor 212 and enters CO₂ regeneration reactor 214 via conduit 220.

First H₂O regeneration reactor 213 establishes the dry CO₂ reduced stream entering via conduit 219 and the wet H₂O removal sorbent entering via conduit 218 at a third temperature of about 40° C. and a pressure less than about 1.5 atmospheres, and the dry CO₂ reduced stream contacts the wet H₂O removal sorbent, transferring an amount of H₂O from the wet H₂O removal sorbent to the dry CO₂ stream, generating a partially regenerated H₂O removal sorbent, and producing an H₂O exhaust stream at a temperature of about 40° C. The H₂O exhaust stream is discharged from first H₂O regeneration reactor 213 via exhaust 221, and partially regenerated H₂O removal sorbent exits first H₂O regeneration reactor 213 and enters second H₂O regeneration reactor via conduit 222.

In an embodiment, the wet H₂O removal sorbent entering first H₂O regeneration reactor 213 via conduit 218 has a first moisture content and the partially regenerated H₂O removal sorbent exiting first H₂O regeneration reactor 213 via conduit 222 has a second moisture content, and the second moisture content is equal to at least 50% of the first moisture content.

In another embodiment, a first moisture content transfer rate is equal to a mass of the H₂O sorbed the wet H₂O removal sorbent entering first H₂O regeneration reactor 213 via conduit 218 per unit time, and similarly, a second moisture content transfer rate is equal to a mass of the H₂O sorbed on the partially regenerated H₂O removal sorbent exiting first H²O regeneration reactor 213 via conduit 222 per unit time. In this embodiment, the second moisture content transfer rate is equal to at least 50% of the first moisture content transfer rate.

In a further embodiment, the gaseous stream entering H₂O capture reactor 211 at inlet 216 exhibits a first mass flow rate of H₂O and the H₂O exhaust stream discharging from first H₂O regeneration reactor 213 via exhaust 221 exhibits a second mass flow rate of H₂O, and the second mass flow rate of H₂O is less than 70% of the first mass flow rate of H₂O. In a further embodiment, the second mass flow rate of H₂O is greater than about 40% and less than about 70% of the first mass flow rate of H₂O.

As described, loaded CO₂ removal sorbent exits CO₂ capture reactor 212 and enters CO₂ regeneration reactor 214 via conduit 220. CO₂ regeneration reactor 214 heats the loaded CO₂ removal sorbent to a fourth temperature of greater than about 160° C. and generally about 200° C., desorbing a gaseous CO₂, generating a regenerated CO₂ removal sorbent, and producing a heated CO₂ stream. The heated CO₂ stream exits CO₂ regeneration reactor 214 and enters second H₂O regeneration reactor 215 via conduit 223, and the regenerated CO₂ removal sorbent exits CO₂ regeneration reactor 214 and enters CO₂ capture reactor 212 via conduit 224. The regenerated CO₂ removal sorbent is subsequently utilized as the CO₂ removal sorbent within CO₂ capture reactor 212.

CO₂ regeneration reactor 214 may use any means known in the art to heat the loaded CO₂ removal sorbent and desorb the gaseous CO₂. In an embodiment, a CO₂ flushing stream comprising some portion of the heated CO₂ stream is withdrawn from conduit 223 via conduit 225 and passed through heating unit 226 receiving heat from, for example, a steam flow through element 227. The CO₂ flushing stream issues from heating unit 226 and enters CO₂ regeneration reactor 214, providing the heat duty necessary to heat the loaded CO₂ removal sorbent to a temperature of greater than about 160° C. and generally about 200° C. Further, in an embodiment, heat transfer from the regenerated CO₂ removal sorbent transferring in conduit 224 to the loaded CO₂ removal sorbent transferring in conduit 220 through, for example, regenerative heat exchanger 233, further reduces the heat duty required by CO₂ regeneration reactor 214.

Second H₂O regeneration reactor 215 establishes the heated CO₂ stream entering via conduit 223 and the partially regenerated H₂O removal sorbent entering via conduit 222 at a fifth temperature of about 60° C. and a pressure less than about 1.5 atmospheres, and the heated CO₂ stream contacts the partially regenerated H₂O removal sorbent, transferring a mass of H₂O from the partially regenerated H₂O removal sorbent to the heated CO₂ stream, generating a regenerated H₂O removal sorbent, and producing a CO₂ exhaust stream at a temperature of about 60° C. The CO₂ exhaust stream is discharged from second H₂O regeneration reactor 215 via exhaust 228, and regenerated H₂O removal sorbent exits second H₂O regeneration reactor 215 and enters H₂O capture reactor 211 via conduit 229. The regenerated H₂O removal sorbent is subsequently utilized as the H₂O removal sorbent within H₂O capture reactor 211.

In an embodiment, the regenerated H₂O removal sorbent exiting second H₂O regeneration reactor 215 via conduit 229 has a third moisture content, and the third moisture content is at least 30% of the first moisture content of the wet H₂O removal sorbent entering first H₂O regeneration reactor 213 via conduit 218. In another embodiment, the third moisture content is at least 50% of the second moisture content of the partially regenerated H₂O removal sorbent entering second H₂O regeneration reactor 215 via conduit 222.

In another embodiment, a third moisture content transfer rate is equal to a mass of the H₂O sorbed on the regenerated H₂O removal sorbent exiting second H₂O regeneration reactor 215 via conduit 229 per unit time, and the third moisture content transfer rate is at least 30% of the first moisture content transfer rate of the sorbed H₂O entering first H₂O regeneration reactor 213 via conduit 218. In another embodiment, the third moisture content transfer rate is at least 50% of the second moisture content transfer rate of the sorbed H₂O entering second H₂O regeneration reactor 215 via conduit 222.

In an additional embodiment, the CO₂ exhaust stream discharging from second H₂O regeneration reactor 215 via exhaust 228 exhibits a third mass flow rate of H₂O, and the third mass flow rate of H₂O is less than about 60% of the first mass flow rate of H₂O exhibited by the gaseous stream entering H₂O capture reactor 211 at inlet 216. In a further embodiment, the third mass flow rate of H₂O is greater than about 30% and less than about 60% of the first mass flow rate of H₂O. In another embodiment, the third mass flow rate of H₂O is less than the second mass flow rate of H₂O exhibited by the H₂O exhaust stream discharging from first H₂O regeneration reactor 213 via exhaust 221.

Within this disclosure, transport of removal sorbents via conduits 218, 220, 222, 224, and 229 may be accomplished in a variety of ways, including moving bed arrangements, fluidized transfer of pellets, and other means known to those skilled in the art. Similarly, the transport of various streams through conduits 216, 217, 219, 221, 223, 225, 227, 228, and 230 may be motivated in a variety of ways, including a pump, a pressure differential between the reactors, and other means known to those skilled in the art.

H₂O capture reactor 211, CO₂ capture reactor 212, first H₂O regeneration reactor 213, and second H₂O regeneration reactor 215 may be any vessel known in the art and sufficient to accept a gaseous stream, accept the various removal sorbents described, initiate contact between the gaseous stream and the various removal sorbents described, and discharge a gaseous stream and a contacted removal sorbent subsequent to the contact, while maintaining specified pressure and temperature conditions during the contact. CO₂ regeneration reactor 214 may be any vessel known in the art and sufficient to accept the loaded CO₂ removal sorbent, heat the loaded CO₂ removal sorbent sufficiently to desorb gaseous CO₂, and discharge a heated CO₂ stream and a regenerated CO₂ removal sorbent subsequent to the contact, while maintaining specified pressure and temperature conditions during the heating. For example, H₂O capture reactor 211, CO₂ capture reactor 212, first H₂O regeneration reactor 213, CO₂ regeneration reactor 214, and second H₂O regeneration reactor 215 may be a packed or fluidized bed reactor, or may incorporate moving beds for transport of the various removal sorbents into and out of the reactor.

Thus, provided here is a method for the removal of H₂O and CO₂ from a gaseous stream comprising H₂O and CO₂ , such as a flue gas. The method utilizes first and second stage regenerations and relatively low temperature partial pressure changes to affect an overall regeneration sufficient for a cyclic operation incorporating H₂O and CO₂ removal. The first and second regenerations generally provide retention of the initial monolayer of moisture on the various described removal sorbents, and typically only act to remove moisture layers bound to the initial monolayer, allowing the Gibbs free energy of mixing to largely compensate for the heats of reaction and largely avoiding the additional heats required for removal of the initial monolayer. Generally the applicable H₂O sorption/desorption processes may be conducted at temperatures less than about 70° C. and pressures less than 1.5 atmospheres, with certain operations conducted at temperatures below 50° C.

It is to be understood that the above-described arrangements are only illustrative of the application of the principles of the present invention and it is not intended to be exhaustive or limit the invention to the precise form disclosed. Numerous modifications and alternative arrangements may be devised by those skilled in the art in light of the above teachings without departing from the spirit and scope of the present invention. It is intended that the scope of the invention be defined by the claims appended hereto.

In addition, the previously described versions of the present invention have many advantages, including but not limited to those described above. However, the invention does not require that all advantages and aspects be incorporated into every embodiment of the present invention.

All publications and patent documents cited in this application are incorporated by reference in their entirety for all purposes to the same extent as if each individual publication or patent document were so individually denoted. 

What is claimed is:
 1. A method of removing CO₂ and H₂O from a gaseous stream comprising: receiving the gaseous stream, where the gaseous stream comprises CO₂ and H₂O; establishing the gaseous stream and an H₂O removal sorbent at a first temperature and contacting the gaseous stream and the H₂O removal sorbent at the first temperature, and transferring a portion of the H₂O from the gaseous stream to the H₂O removal sorbent, thereby generating a wet H₂O removal sorbent and thereby generating a dry gaseous stream, where the wet H₂O removal sorbent comprises the H₂O removal sorbent and the portion of the H₂O transferred and where the dry gaseous stream comprises the gaseous stream less the portion of the H₂O transferred; establishing the dry gaseous stream and a CO₂ removal sorbent at a second temperature and contacting the dry gaseous stream and the CO₂ removal sorbent at the second temperature, and transferring a portion of the CO₂ from the dry gaseous stream to the CO₂ removal sorbent, thereby generating a loaded CO₂ removal sorbent and thereby generating a dry CO₂ reduced stream, where the loaded CO₂ removal sorbent comprises the CO₂ removal sorbent and the portion of the CO₂ transferred and where the dry CO₂ reduced stream comprises the dry gaseous stream less the portion of the CO₂ transferred; establishing the dry CO₂ reduced stream and the wet H₂O removal sorbent at a third temperature and contacting the dry CO₂ reduced stream and the wet H₂O removal sorbent at the third temperature, and transferring a first quantity of H₂O from the wet H₂O removal sorbent to the dry CO₂ reduced stream, where the first quantity of H₂O is an amount of the portion of the H₂O transferred from the gaseous stream to the H₂O removal sorbent, thereby generating a partially regenerated H₂O removal sorbent and thereby generating an H₂O exhaust stream, where the partially regenerated H₂O removal sorbent comprises the wet H₂O removal sorbent less the first quantity of H₂O transferred and where the H₂O exhaust stream comprises the dry CO₂ reduced stream and the first quantity of H₂O transferred; heating the loaded CO₂ removal sorbent to a fourth temperature greater than the second temperature and desorbing a gaseous CO₂ from the loaded CO₂ removal sorbent, thereby generating a regenerated CO₂ removal sorbent and thereby generating a heated CO₂ stream, where the regenerated CO₂ removal sorbent comprises the loaded CO₂ removal sorbent less the gaseous CO₂ desorbed and where the heated CO₂ stream comprises the gaseous CO₂ desorbed; establishing the heated CO₂ stream and the partially regenerated H₂O removal sorbent at a fifth temperature greater than the third temperature and contacting the heated CO₂ stream and the partially regenerated H₂O removal sorbent at the fifth temperature, and transferring a second quantity of H₂O from the partially regenerated H₂O removal sorbent to the heated CO₂ stream, where the second quantity of H₂O is another amount of the portion of the H₂O transferred from the gaseous stream to the H₂O removal sorbent, thereby generating a regenerated H₂O removal sorbent and thereby generating a CO₂ exhaust stream, where the regenerated H₂O removal sorbent comprises the partially regenerated H₂O removal sorbent less the second quantity of H₂O and where the CO₂ exhaust stream comprises the heated CO₂ stream and the second quantity of H₂O; and repeating the receiving a gaseous stream step, the establishing the gaseous stream and the dry H₂O removal sorbent at the first temperature step, the establishing the dry gaseous stream and the CO₂ removal sorbent at the second temperature step, the establishing the dry CO₂ reduced stream and the wet H₂O removal sorbent at the third temperature step, the heating the loaded CO₂ removal sorbent to the fourth temperature step, and the establishing the heated CO₂ stream and the partially regenerated H₂O removal sorbent at the fifth temperature step using the regenerated H₂O removal sorbent as the H₂O removal sorbent and using the regenerated CO₂ removal sorbent as the CO₂ removal sorbent.
 2. The method of claim 1 where the wet H₂O removal sorbent has a first moisture content and where the partially regenerated H₂O removal sorbent has a second moisture content, and where the second moisture content is equal to at least 50% of the first moisture content.
 3. The method of claim 2 where the regenerated H₂O removal sorbent has a third moisture content, and where the third moisture content is equal to at least 30% of the first moisture content.
 4. The method of claim 3 where the third moisture content is equal to at least 50% of the second moisture content.
 5. The method of claim 4 where the H₂O removal sorbent has an initial moisture content, and where the initial moisture content is equal to at least 30% of the first moisture content and equal to at least 50% of the second moisture content.
 6. The method of claim 5 where the first temperature, the second temperature, the third temperature, and the fifth temperature are less than 70° C.
 7. The method of claim 6 where the first temperature, the second temperature, and the third temperature are less than 50° C. and where the fifth temperature is greater than 50° C.
 8. The method of claim 7 further comprising contacting the gaseous stream and the H₂O removal sorbent at a first pressure, contacting the dry gaseous stream and the CO₂ removal sorbent at a second pressure, contacting the dry CO₂ reduced stream and the wet H₂O removal sorbent at a third pressure, heating the loaded CO₂ loyal sorbent at a fourth pressure, and contacting the heated CO₂ stream and the partially regenerated H₂O removal sorbent at a fifth pressure, where the first pressure, the second pressure, and the fifth pressure are less than 1.5 atmospheres.
 9. The method of claim 8 where the H₂O removal sorbent comprises a material having a specific surface area greater than 300 m2 per gram of the material and a pore greater than 0.40 ml per gram of the material.
 10. The method of claim 9 where the material is an activated alumina, a 3A zeolite, a 4A zeolite, a silica gel, an absorbent clay, or mixtures thereof.
 11. The method of claim 1 where the gaseous stream provides a first mass flow rate of H₂O and where the H₂O exhaust stream provides a second mass flow rate of H₂O, and where the second mass flow rate of H₂O is less than 70% of the first mass flow rate of H₂O.
 12. The method of claim 11 where the second mass flow rate of H₂O is greater than about 40% of the first mass flow rate of H₂O.
 13. The method of claim 12 where the CO₂ exhaust stream provides a third mass flow rate of H₂O, where the third mass flow rate of H₂O is greater than or equal to 30% of the first mass flow rate of H₂O and less than or equal to 60% of the first mass flow rate of H₂O.
 14. The method of claim 13 where the first temperature, the second temperature, and the third temperature are less than 50° C., where the fourth temperature is greater than 160° C., and where the fifth temperature is greater than 50° C. and less than 70° C.
 15. A method of removing CO₂ and H₂O from a gaseous stream comprising: contacting the gaseous stream and an H₂O removal sorbent in a H₂O capture reactor at a first temperature, where the gaseous stream comprises CO₂ and H₂O, and transferring a portion of the H₂O from the gaseous stream to the H₂O removal sorbent, thereby generating a wet H₂O removal sorbent and thereby generating a dry gaseous stream, where the wet H₂O removal sorbent comprises the H₂O removal sorbent and the portion of the H₂O transferred and where the dry gaseous stream comprises the gaseous stream less the portion of the H₂O transferred; discharging the dry gaseous stream from the H₂O capture reactor to a CO₂ capture reactor; transferring the wet H₂O removal sorbent from the H₂O capture reactor to a first H₂O regeneration reactor; contacting the dry gaseous stream and a CO₂ removal sorbent in the CO₂ capture reactor at a second temperature and transferring a portion of the CO₂ from the dry gaseous stream to the CO₂ removal sorbent, thereby generating a loaded CO₂ removal sorbent and thereby generating a dry CO₂ reduced stream, where the loaded CO₂ removal sorbent comprises the CO₂ removal sorbent and the portion of the CO₂ transferred and where the dry CO₂ reduced stream comprises the dry gaseous stream less the portion of the CO₂ transferred; discharging the dry CO₂ reduced stream from the CO₂ capture reactor to the first H₂O regeneration reactor; transferring the loaded CO₂ removal sorbent from the CO₂ capture reactor to a CO₂ regeneration reactor; contacting the dry CO₂ reduced stream and the wet H₂O removal sorbent in the first H₂O regeneration reactor at a third temperature and transferring a first quantity of H₂O from the wet H₂O removal sorbent to the dry CO₂ reduced stream, where the first quantity of H₂O is an amount of the portion of the H²O transferred from the gaseous stream the H₂O removal sorbent, thereby generating a partially regenerated H₂O removal sorbent and thereby generating an H₂O exhaust stream, where the partially regenerated H₂O removal sorbent comprises the wet H₂O removal sorbent less the first quantity of H₂O transferred and where the H₂O exhaust stream comprises the dry CO₂ reduced stream and the first quantity of H₂O transferred; exhausting the H₂O exhaust stream from the first H₂O regeneration reactor; transferring the partially regenerated H₂O removal sorbent from the first H₂O regeneration reactor to a second H₂O regeneration reactor; heating the loaded CO₂ removal sorbent in the CO₂ regeneration reactor to a fourth temperature greater than the second temperature and desorbing a gaseous CO₂ from the loaded CO₂ removal sorbent, thereby generating a regenerated CO₂ removal sorbent and thereby generating a heated CO₂ stream, where the regenerated CO₂ removal sorbent comprises the loaded CO₂ removal sorbent less the gaseous CO₂ desorbed and where the heated CO₂stream comprises the gaseous CO₂ desorbed; discharging the heated CO₂ stream from the CO₂ regeneration reactor to the second H₂O regeneration reactor; contacting the heated CO₂ stream and the partially regenerated H₂O removal sorbent in the second H₂O regeneration reactor at a fifth temperature, where the fifth temperature is greater than the third temperature, and transferring a second quantity of H₂O from the partially regenerated H₂O removal sorbent to the heated CO₂ stream, where the second quantity of H₂O is another amount of the portion of the H₂O transferred from the gaseous stream to the H₂O removal sorbent, thereby generating a regenerated H₂O removal sorbent and thereby generating a CO₂ exhaust stream, where the regenerated H₂O removal sorbent comprises the partially regenerated H₂O removal sorbent less the second quantity of H₂O and where the CO₂ exhaust stream comprises the heated CO₂ stream and the second quantity of H₂O; exhausting the CO₂ exhaust stream from the second H₂O regeneration reactor; transferring the regenerated H₂O removal sorbent from the second H₂O regeneration reactor to the H₂O capture reactor and transferring the regenerated CO₂ removal sorbent from the CO₂ regeneration reactor to the CO₂ capture reactor, and repeating the contacting the gaseous stream and the H₂O removal sorbent step, the discharging the dry gaseous stream step, the transferring the wet H₂O removal sorbent step, the contacting the dry gaseous stream and the CO₂ removal sorbent step, the discharging the dry CO₂ reduced stream step, the transferring the loaded CO₂ removal sorbent step, the contacting the dry CO₂ reduced stream and the wet H₂O removal sorbent step, the exhausting the H₂O exhaust stream step, the transferring the partially regenerated H₂O removal sorbent step, the heating the loaded CO₂ removal sorbent step, the discharging the heated CO₂ stream step, the contacting the heated CO₂ stream and the partially regenerated H₂O removal sorbent step, and the exhausting the CO₂ exhaust stream step, using the regenerated H₂O removal sorbent as the H₂O removal sorbent and using the regenerated CO₂ removal sorbent as the CO₂ removal sorbent.
 16. The method of claim 15 where a first moisture content transfer rate is equal to a mass of H₂O sorbed on the wet H₂O removal sorbent and transferred to the first H₂O regeneration reactor per unit time, and where a second moisture content transfer rate equal to a mass of H₂O sorbed on the partially regenerated H₂O removal sorbent and transferred from the first H₂O regeneration reactor per unit time, and where the second moisture content transfer rate is equal to at least 50% of the first moisture content transfer rate.
 17. The method of claim 16 where a third moisture content transfer rate is equal to a mass of H₂O sorbed on the regenerated H₂O removal sorbent and transferred from the second H₂O regeneration reactor per unit time, and where the third moisture content transfer rate is at least 30% of the first moisture content transfer rate and at least 50% of the second moisture content transfer rate.
 18. The method of claim 17 where the first temperature, the second temperature, and the third temperature are less than 50° C., and where the fifth temperature is greater than 50° C. and less than 70° C.
 19. The method of claim 18 further comprising maintaining the H₂O capture reactor at a first pressure, maintaining the CO₂ capture reactor at a second pressure, maintaining the first H₂O regeneration reactor at a third pressure, maintaining the CO₂ regeneration reactor at a fourth pressure, and maintaining the second H₂O regeneration reactor at a fifth pressure, where the first pressure, the second pressure, and the fifth pressure are less than 1.5 atmospheres.
 20. The method of claim 19 where the H₂O removal sorbent comprises a material having a specific surface area greater than 300 m² per gram of the material and a pore volume greater than 0.40 ml per gram of the material. 